Enterprise Products Partners LP Reports In-line

Enterprise Products Partners LP (EPD) reported 3rd Quarter September 2016 earnings of $0.30 per share on revenue of $5.9 billion. The consensus earnings estimate was $0.30 per share on revenue of $5.8 billion. The Earnings Whisper number was $0.30 per share. Revenue fell 6.1% compared to the same quarter a year ago.

Enterprise Reports Results for Third Quarter 2016

Enterprise Products Partners L.P. ("Enterprise") (EPD) today
announced its financial results for the three and nine months ended
September 30, 2016.

Third Quarter 2016 Highlights

Three months ended

Nine months ended

September 30,

September 30,

2016

2015

2016

2015

($ in millions, except per unit amounts)

Operating income

$

905

$

909

$ 2,658

$ 2,606

Net income

$

643

$

658

$ 1,883

$ 1,865

Fully diluted earnings per unit

$

0.30

$

0.32

$

0.89

$

0.92

Net cash flow provided by operating activities (1)

$

854

$

690

$ 2,699

$ 2,591

Total gross operating margin (2)

$ 1,312

$ 1,349

$ 3,891

$ 3,985

Adjusted EBITDA (2)

$ 1,259

$ 1,310

$ 3,901

$ 3,932

Distributable cash flow (2) (3)

$

978

$ 2,501

$ 3,072

$ 4,519

(1)

Net cash flow provided by operating activities includes the impact

of timing of cash receipts and payments related to operations. For

the third quarters of 2016 and 2015, the net effect of changes in

operating accounts, which are a component of net cash flow provided

by operating activities, were reductions of $155 million and $377

million, respectively.

(2)

Total gross operating margin, adjusted earnings before interest,

taxes, depreciation and amortization ("Adjusted EBITDA") and

distributable cash flow are non-generally accepted accounting

principle ("non-GAAP") financial measures that are defined and

reconciled later in this press release.

(3)

Distributable cash flow includes cash proceeds from asset sales and

insurance recoveries of $16 million and $1.5 billion for the third

quarters of 2016 and 2015, respectively, and $44 million and $1.5

billion for the nine months ended September 30, 2016 and 2015,

respectively. Distributable cash flow for the third quarter and nine

months ended September 30, 2015 includes cash proceeds from the sale

of the partnerships offshore business in July 2015.

•
Enterprise increased its cash distribution with respect to the third
quarter of 2016 by 5.2 percent to $0.405 per unit compared to the
distribution paid with respect to the third quarter of 2015. The
distribution will be paid November 7, 2016 to unitholders of record as
of the close of business on October 31, 2016.

•
Enterprise reported distributable cash flow of $978 million for the
third quarter of 2016, which provided 1.15 times coverage of the
$0.405 per unit cash distribution and resulted in $124 million of
retained distributable cash flow. For the nine months ended September
30, 2016, distributable cash flow was $3.1 billion, which provided
1.22 times coverage of the aggregate $1.20 per unit cash distribution,
and Enterprise retained $551 million of distributable cash flow, which
is available to reinvest in growth capital projects and reduce the
need to issue additional equity.

•
Excluding cash proceeds from asset sales and insurance recoveries,
distributable cash flow for the third quarter of 2016 was $962 million
compared to $970 million for the third quarter of 2015.

--
Third Quarter Volume Highlights

Three months

ended Sept. 30,

2016

2015

Onshore NGL, crude oil, refined products & petrochemical pipeline

5.0

5.2

volumes (million BPD)

Marine terminal volumes (million BPD)

1.2

1.3

Onshore natural gas pipeline volumes (TBtu/d)

12.1

12.4

NGL fractionation volumes (MBPD)

791

837

Fee-based natural gas processing volumes (Bcf/d)

4.6

5.0

Equity NGL production volumes (MBPD)

116

129

As used in this press release, "NGL" means natural gas liquids,

"BPD" means barrels per day, "MBPD" means thousand barrels per day,

"Bcf/d" means billion cubic feet per day; and "TBtu/d" means

trillion British thermal units per day.

•
Capital investments were $621 million in the third quarter of 2016,
and $2.6 billion for the first nine months of 2016. Included in these
investments were sustaining capital expenditures of $62 million and
$179 million for the third quarter and first nine months of 2016,
respectively. These amounts exclude $1.0 billion that Enterprise paid
in July 2016 for the second and final installment payment for the
acquisition of the EFS Midstream assets.

"Enterprise reported another solid quarter in light of the challenging
environment for the global energy industry," said Jim Teague, chief
executive officer of Enterprises general partner. "We are proud of our
employees for their untiring efforts in the commercial, operational and
financial performance of the partnership. For the third quarter of 2016,
Enterprise generated $1 billion in distributable cash flow, increased
our distribution to partners by 5.2 percent and retained $124 million of
distributable cash flow to reinvest in the business. During the quarter,
we transported over 5 million barrels per day through our liquids
pipelines and handled over 1.2 million barrels per day at our marine
terminals. Increases in gross operating margin from many of our
fee-based businesses partially offset the effects of lower earnings from
our commodity sensitive businesses, lower volumes on our Eagle Ford
crude oil pipelines, weaker ethane recoveries industry-wide, downtime
and repairs at our Pascagoula natural gas processing plant and
pre-commissioning expenses for certain new assets."

"We are optimistic that the energy industry has weathered the harshest
part of this cycle and very proud of how our businesses continued to
perform. While the industry may still experience bouts of commodity
price weakness and volatility, we believe it has a firmer foundation
going into 2017 as the gap between supply and demand has narrowed and
should continue to do so. We are seeing significant green shoots of
producer activity as a result of the opportunity to hedge future sales
of crude, NGLs and natural gas at economic levels. In addition to the
acceleration of investment in the Permian Basin, we are seeing activity
attributable to new discoveries, deployment of new technology, including
in well-established areas such as the Eagle Ford and Haynesville; and
changes in ownership of acreage as some producers emerge from
restructuring.

"From the perspective of consumers of energy, a substantial increase in
demand for natural gas and NGLs is expected from new domestic
petrochemical, natural gas-fired power plants and LNG facilities under
construction and scheduled to begin operations over the next one to
three years. Through the end of 2017, five new ethylene facilities on
the U.S. Gulf Coast are scheduled to begin operations that represent
333,000 barrels per day, or 30 percent increase in demand for ethane. In
addition, certain refining and petrochemical customers are evaluating
new facilities or modifications to existing facilities that will require
additional midstream energy infrastructure."

"We currently have $5.6 billion of growth capital projects under
construction that will begin commercial service between now and the end
of 2018, including our PDH facility, the Midland-to-Sealy crude oil
pipeline and a third natural gas processing plant in the Delaware Basin.
We expect these projects to support continued distribution growth for
our partners," continued Teague.

Review of Third Quarter 2016 Results

NGL Pipelines & Services - Gross operating margin for the NGL
Pipelines & Services segment increased to $704 million for the third
quarter of 2016 from $696 million for the third quarter of 2015.

Enterprises natural gas processing and related NGL marketing business
generated gross operating margin of $203 million for the third quarters
of both 2016 and 2015. Gross operating margin for the third quarter of
2016 benefited from higher processing margins, including hedging
activities, and a $13 million increase from the partnerships NGL
marketing activities due in part to increased liquefied petroleum gases
("LPG") loadings for export. Offsetting these increases to gross
operating margin were lower fees and volumes from fee-based processing
at Enterprises South Texas, Rockies and Louisiana gas processing
plants, and a $7 million increase in operating expenses as the result of
a fire at our Pascagoula, Mississippi natural gas processing plant in
June 2016. We estimate the total impact of the Pascagoula plant outage
during the third quarter of 2016 in terms of higher operating expense,
lost gross operating margin opportunity and sustaining capital
expenditures was approximately $23 million. We currently expect the
plant to resume operations in December 2016.

Enterprises natural gas processing plants reported fee-based processing
volumes of 4.6 Bcf/d in the third quarter of 2016 compared to 5.0 Bcf/d
for the third quarter of 2015. Equity NGL production was 116 MBPD for
the third quarter of 2016 compared to 129 MBPD for the third quarter of
last year. A significant portion of the decrease in the fee-based
processing volumes and equity NGL production was attributable to down
time at the Pascagoula plant.

Gross operating margin from the partnerships NGL pipelines and storage
business increased to $378 million for the third quarter of 2016 from
$366 million for the third quarter of 2015. Total NGL transportation
volumes were 2.9 million BPD for the third quarter of 2016 compared to
2.8 million BPD for the same quarter of 2015.

Enterprises ATEX and Aegis ethane pipelines reported a $27 million
increase in gross operating margin for the third quarter of 2016
compared to the third quarter of last year on a 112 MBPD increase in
transportation volumes. The third and final segment of the Aegis ethane
pipeline was completed in December 2015. Gross operating margin for the
third quarter of 2016 increased $9 million from a 30 MBPD increase in
LPG loadings at our marine terminal on the Houston Ship Channel compared
to the same quarter in 2015. Partially offsetting these increases in
gross operating margin were lower transportation fees and volumes on the
Mid-America and Seminole pipelines which led to a $13 million decrease
in gross operating margin. Also contributing to lower gross operating
margin this quarter was an aggregate 74 MBPD decrease in NGL
transportation volumes from the partnerships Dixie, South Louisiana,
Rio Grande and Tri-States NGL pipelines that led to an aggregate $11
million decrease in gross operating margin.

Enterprises ethane export terminal, which is located on the Houston
Ship Channel, began commercial service in September 2016 loading an
average of 20 MBPD of ethane in the third quarter. Gross operating
margin for the facility in the third quarter of 2016, including
commissioning expenses, was a loss of $3 million. Contract commitments
for this facility increase to 50 MBPD by the end of 2016 and will
increase to approximately 180 MBPD by the end of 2017.

Gross operating margin from the partnerships NGL fractionation business
was $122 million for the third quarter of 2016 compared to $126 million
for the third quarter of 2015, a $4 million decrease primarily due to
lower fractionation volumes. Total fractionation volumes decreased 46
MBPD to 791 MBPD for the third quarter of 2016 compared to 837 MBPD for
the third quarter of 2015 primarily due to ethane rejection at regional
natural gas processing facilities.

Crude Oil Pipelines & Services - Gross operating margin from
the partnerships Crude Oil Pipelines & Services segment was $254
million for the third quarter of 2016 compared to $255 million for the
third quarter of 2015. Total crude oil pipeline transportation volumes
were 1.4 million BPD for the third quarter of 2016 compared to 1.5
million BPD for the same quarter of 2015. Total crude oil marine
terminal volumes were 520 MBPD for the third quarter of 2016 compared to
551 MBPD for the third quarter of 2015.

The EFS Midstream assets that we acquired effective July 1, 2015, had a
$15 million increase in gross operating margin this quarter compared to
the third quarter of last year primarily due to higher revenues and
lower costs that more than offset the impact of lower volumes.
Enterprise completed construction and put into service over 9 million
barrels of additional storage capacity at the partnerships ECHO, EHT
and Beaumont facilities since the third quarter of 2015. These new
storage tanks contributed toward a $13 million increase in gross
operating margin in the third quarter of 2016 compared to the third
quarter of last year for these facilities.

Enterprises South Texas and Eagle Ford Crude Oil Pipeline Systems
reported an aggregate $28 million decrease in gross operating margin for
the third quarter of 2016 compared to the third quarter of 2015
primarily due to lower volumes. Pipeline volumes on these systems, net
to our interest, were 351 MBPD for the third quarter of 2016 compared to
449 MBPD for the same quarter of 2015. Gross operating margin from
Enterprises crude oil marketing and related activities decreased $6
million this quarter compared to the third quarter of 2015.

Natural Gas Pipelines & Services - Gross operating margin
from the partnerships Natural Gas Pipelines & Services segment was $179
million for the third quarter of 2016 compared to $192 million for the
third quarter of 2015. Total natural gas transportation volumes were
12.1 TBtu/d for the third quarter of 2016 compared to 12.4 TBtu/d for
the same quarter of last year. The Texas Intrastate System reported a
$16 million decrease in gross operating margin primarily due to lower
revenues attributable to reduced producer drilling activity in the Eagle
Ford and Barnett Shale. Natural gas pipeline volumes for this system
were 4.9 TBtu/d for the third quarter of 2016 compared to 5.0 TBtu/d for
the third quarter of 2015.

Petrochemical & Refined Products Services - Gross operating
margin for the Petrochemical & Refined Products Services segment was
$172 million for the third quarter of 2016 compared to $192 million for
the third quarter of 2015. Total segment pipeline transportation volumes
were 784 MBPD for the third quarter of 2016 compared to 816 MBPD for the
same quarter of 2015.

Enterprises refined products pipelines and related services business
reported a 34 percent increase in gross operating margin for the third
quarter of 2016 to $71 million from $53 million for the third quarter of
2015. Gross operating margin from the TE Products Pipeline and related
terminals increased $14 million primarily as a result of lower operating
expenses. The partnerships refined products marine terminal in Beaumont
contributed $9 million to the increase in gross operating margin,
primarily due to higher demand for storage and marine vessel loading
services.

The partnerships propylene business reported a 23 percent increase in
gross operating margin to $57 million for the third quarter of 2016 from
$47 million for the third quarter of 2015. This increase was primarily
due to higher sales margins, including those from record propylene
exports, and lower maintenance expenses. The increase was partially
offset by pre-commissioning expenses associated with our propane
dehydrogenation plant ("PDH") in Mont Belvieu of $7 million for the
third quarter of 2016. The PDH facility is under construction and is
expected to begin commissioning activities in the second quarter of
2017. Propylene fractionation volumes were 76 MBPD for the third quarter
of 2016 compared to 72 MBPD for the third quarter of last year.

Gross operating margin for Enterprises octane enhancement and
high-purity isobutylene business was $17 million for the third quarter
of 2016 versus $58 million for the third quarter of last year. The
decrease was primarily due to lower sales margins, including hedging
activities. Sales margins in this business were impacted in part by
higher global inventories of gasoline products. Total production volumes
from these plants were 27 MBPD for the third quarter of 2016 compared to
20 MBPD for the third quarter of last year.

Offshore Pipelines & Services - Enterprise closed on the sale
of its offshore Gulf of Mexico business on July 24, 2015. As a result,
the partnership had no contribution to gross operating margin from these
assets in the third quarter of 2016 compared to $7 million in the third
quarter of 2015.

Capitalization

Total debt principal outstanding at September 30, 2016 was $24.2
billion, including $1.5 billion of junior subordinated notes to which
the nationally recognized debt rating agencies ascribe partial equity
content. Approximately $1.0 billion of this debt is attributable to
working capital and restricted cash associated with our marketing
businesses, including capital related to contango opportunities. This
marketing-related working capital and related debt is expected to
decrease monthly through the first quarter of 2017. At September 30,
2016, Enterprise had consolidated liquidity of $3.5 billion, which was
comprised of unrestricted cash on hand and available borrowing capacity
under our revolving credit facilities.

Total capital spending in the third quarter of 2016 was $621 million,
which includes $62 million of sustaining capital expenditures. For the
first nine months of 2016, Enterprises capital spending was $2.6
billion including $179 million of sustaining capital expenditures. For
2016, we currently expect to invest approximately $2.8 billion for
growth projects and approximately $250 million for sustaining capital
expenditures. These amounts exclude $1.0 billion that Enterprise paid in
July 2016 for the second and final installment payment for the
acquisition of the EFS Midstream assets.

Conference Call to Discuss Third Quarter 2016
Earnings

Today, Enterprise will host a conference call to discuss third quarter
2016 earnings. The call will be broadcast live over the Internet
beginning at 9:00 a.m. CT and may be accessed by visiting the
partnerships website at www.enterpriseproducts.com.

Use of Non-GAAP Financial Measures

This press release and accompanying schedules include the non-GAAP
financial measures of total gross operating margin, distributable cash
flow and Adjusted EBITDA. The accompanying schedules provide definitions
of these non-GAAP financial measures and reconciliations to their most
directly comparable financial measure calculated and presented in
accordance with GAAP. Our non-GAAP financial measures should not be
considered as alternatives to GAAP measures such as net income,
operating income, net cash flow provided by operating activities or any
other measure of financial performance calculated and presented in
accordance with GAAP. Our non-GAAP financial measures may not be
comparable to similarly-titled measures of other companies because they
may not calculate such measures in the same manner as we do.

Company Information and Use of Forward-Looking
Statements

Enterprise Products Partners L.P. is one of the largest publicly traded
partnerships and a leading North American provider of midstream energy
services to producers and consumers of natural gas, NGLs, crude oil,
refined products and petrochemicals. Our services include: natural gas
gathering, treating, processing, transportation and storage; NGL
transportation, fractionation, storage and import and export terminals;
crude oil gathering, transportation, storage and terminals;
petrochemical and refined products transportation, storage and
terminals; and a marine transportation business that operates primarily
on the United States inland and Intracoastal Waterway systems. The
partnerships assets include approximately 49,000 miles of pipelines;
250 million barrels of storage capacity for NGLs, crude oil, refined
products and petrochemicals; and 14 billion cubic feet of natural gas
storage capacity.

This press release includes forward-looking statements. Except
for the historical information contained herein, the matters discussed
in this press release are forward-looking statements that involve
certain risks and uncertainties, such as the partnerships expectations
regarding future results, capital expenditures, project completions,
liquidity and financial market conditions. These risks and
uncertainties include, among other things, insufficient cash from
operations, adverse market conditions, governmental regulations and
other factors discussed in Enterprises filings with the U.S. Securities
and Exchange Commission. If any of these risks or uncertainties
materialize, or should underlying assumptions prove incorrect, actual
results or outcomes may vary materially from those expected. The
partnership disclaims any intention or obligation to update publicly or
reverse such statements, whether as a result of new information, future
events or otherwise.

Enterprise Products Partners L.P.

Exhibit A

Condensed Statements of Consolidated Operations - UNAUDITED

($ in millions, except per unit amounts)

For the Three Months

For the Nine Months

Ended September 30,

Ended September 30,

2016

2015

2016

2015

Revenues

$

5,920.4

$

6,307.9

$ 16,543.5

$ 20,872.9

Costs and expenses:

Operating costs and expenses

5,065.7

5,452.6

14,034.8

18,426.5

General and administrative costs

42.0

49.0

121.0

143.2

Total costs and expenses

5,107.7

5,501.6

14,155.8

18,569.7

Equity in income of unconsolidated affiliates

92.3

103.1

269.8

302.5

Operating income

905.0

909.4

2,657.5

2,605.7

Other income (expense):

Interest expense

(250.9 )

(243.7 )

(735.6 )

(723.2 )

Other, net

(6.2 )

(2.5 )

(25.5 )

(13.2 )

Total other expense

(257.1 )

(246.2 )

(761.1 )

(736.4 )

Income before income taxes

647.9

663.2

1,896.4

1,869.3

Provision for income taxes

(4.8 )

(5.5 )

(13.1 )

(4.4 )

Net income

643.1

657.7

1,883.3

1,864.9

Net income attributable to noncontrolling

(8.5 )

(8.4 )

(29.0 )

(28.5 )

interests

Net income attributable to limited partners

$

634.6

$

649.3

$

1,854.3

$

1,836.4

Per unit data (fully diluted):

Earnings per unit

$

0.30

$

0.32

$

0.89

$

0.92

Average limited partner units outstanding (in millions)

2,105.5

2,010.5

2,079.8

1,993.3

Supplemental financial data:

Net cash flow provided by operating activities

$

853.8

$

689.6

$

2,699.0

$

2,591.2

Total debt principal outstanding at end of period

$ 24,163.0

$ 22,497.8

$ 24,163.0

$ 22,497.8

Non-GAAP distributable cash flow (1)

$

978.4

$

2,501.3

$

3,071.7

$

4,518.5

Non-GAAP Adjusted EBITDA (2)

$

1,258.9

$

1,309.9

$

3,900.8

$

3,932.2

Gross operating margin by segment:

NGL Pipelines & Services

$

703.5

$

695.5

$

2,206.3

$

2,041.3

Crude Oil Pipelines & Services

254.0

254.6

633.7

704.2

Natural Gas Pipelines & Services

178.5

192.4

533.6

588.3

Petrochemical & Refined Products Services

171.6

191.5

501.9

547.4

Offshore Pipelines & Services

--

7.1

--

97.5

Total segment gross operating margin (3)

1,307.6

1,341.1

3,875.5

3,978.7

Net adjustment for shipper make-up rights (4)

4.4

7.5

15.0

6.0

Non-GAAP total gross operating margin (5)

$

1,312.0

$

1,348.6

$

3,890.5

$

3,984.7

Capital spending:

Capital expenditures, net (6)

$

593.0

$

988.9

$

2,449.8

$

2,619.1

Equity consideration issued for Step 2 of Oiltanking acquisition

--

--

--

1,408.7

Cash used for business combinations, net of cash received

1,000.0

1,045.1

1,000.0

1,045.1

Investments in unconsolidated affiliates

27.5

16.6

119.9

130.7

Other investing activities

0.4

--

0.4

5.3

Total capital spending, cash and non-cash

$

1,620.9

$

2,050.6

$

3,570.1

$

5,208.9

(1)

See Exhibit D for reconciliation to GAAP net cash flow provided by

operating activities.

(2)

See Exhibit E for reconciliation to GAAP net cash flow provided by

operating activities.

(3)

Within the context of this table, total segment gross operating

margin represents a subtotal and corresponds to measures similarly

titled within the financial statement footnotes provided in our

quarterly and annual filings with the U.S. Securities and Exchange

Commission ("SEC").

(4)

Gross operating margin by segment for NGL Pipelines & Services and

Crude Oil Pipelines & Services reflects adjustments for

non-refundable deferred transportation revenues relating to the

make-up rights of committed shippers on certain major pipeline

projects. These adjustments are included in managements

evaluation of segment results. However, these adjustments are

excluded from non-GAAP total gross operating margin in compliance

with recently issued guidance from the SEC.

(5)

See Exhibit F for reconciliation to GAAP total operating income.

(6)

Capital expenditures for property, plant and equipment are

presented net of contributions in aid of construction cost.

Enterprise Products Partners L.P.

Exhibit B

Selected Operating Data - UNAUDITED

For the Three Months

For the Nine Months

Ended September 30,

Ended September 30,

2016

2015

2016

2015

Selected operating data: (1)

NGL Pipelines & Services, net:

NGL pipeline transportation volumes (MBPD)

2,854

2,831

2,933

2,647

NGL marine terminal volumes (MBPD)

373

324

439

294

NGL fractionation volumes (MBPD)

791

837

822

819

Equity NGL production (MBPD) (2)

116

129

136

129

Fee-based natural gas processing (MMcf/d) (3)

4,578

5,035

4,857

4,911

Crude Oil Pipelines & Services, net:

Crude oil transportation volumes (MBPD)

1,397

1,535

1,383

1,463

Crude oil marine terminal volumes (MBPD)

520

551

504

595

Natural Gas Pipelines & Services, net:

Natural gas transportation volumes (BBtus/d) (4)

12,130

12,387

12,053

12,459

Petrochemical & Refined Products Services, net:

Propylene fractionation volumes (MBPD)

76

72

75

71

Butane isomerization volumes (MBPD)

113

108

112

90

Standalone DIB processing volumes (MBPD)

85

89

90

79

Octane additive and related plant production volumes (MBPD)

27

20

19

17

784

816

836

777

Pipeline transportation volumes, primarily refined products and

petrochemicals (MBPD)

354

387

381

362

Refined products and petrochemicals marine terminal volumes (MBPD)

Offshore Pipelines & Services, net:

Natural gas transportation volumes (BBtus/d)

--

565

--

587

Crude oil transportation volumes (MBPD)

--

344

--

357

Platform natural gas processing (MMcf/d)

--

82

--

101

Platform crude oil processing (MBPD)

--

9

--

13

Total, net:

5,035

5,526

5,152

5,244

NGL, crude oil, refined products and petrochemical transportation

volumes (MBPD)

Natural gas transportation volumes (BBtus/d)

12,130

12,952

12,053

13,046

Equivalent transportation volumes (MBPD) (5)

8,227

8,934

8,324

8,677

1,247

1,262

1,324

1,251

NGL, crude oil, refined products and petrochemical marine terminal

volumes (MBPD)

(1)

Operating rates are reported on a net basis, which takes into

account our ownership interests in certain joint ventures, and

include volumes for newly constructed assets from the related

in-service dates and for recently purchased assets from the related

acquisition dates.

(2)

Represents the NGL volumes we earn and take title to in connection

with our processing activities.

(3)

Volumes reported correspond to the revenue streams earned by our gas

plants. "MMcf/d" means million cubic feet per day.

(4)

"BBtus/d" means billion British thermal units per day.

(5)

Represents total NGL, crude oil, refined products and petrochemical

transportation volumes plus equivalent energy volumes where 3.8

million British thermal units ("MMBtus") of natural gas

transportation volumes are equivalent to one barrel of NGLs

transported.

Enterprise Products Partners L.P.

Exhibit C

Selected Commodity Price Information

Polymer

Refinery

Natural

Normal

Natural

Grade

Grade

WTI

LLS

Gas,

Ethane,

Propane,

Butane,

Isobutane,

Gasoline,

Propylene,

Propylene,

Crude Oil,

Crude Oil,

$/MMBtu

$/gallon

$/gallon

$/gallon

$/gallon

$/gallon

$/pound

$/pound

$/barrel

$/barrel

(1)

(2)

(2)

(2)

(2)

(2)

(3)

(3)

(4)

(4)

2015 by quarter:

1st Quarter

$2.99

$0.19

$0.53

$0.68

$0.68

$1.10

$0.50

$0.37

$48.63

$52.83

2nd Quarter

$2.65

$0.18

$0.46

$0.59

$0.60

$1.26

$0.42

$0.29

$57.94

$62.97

3rd Quarter

$2.77

$0.19

$0.40

$0.55

$0.55

$0.98

$0.33

$0.21

$46.43

$50.17

4th Quarter

$2.27

$0.18

$0.42

$0.60

$0.61

$0.97

$0.31

$0.18

$42.18

$43.54

YTD 2015 Averages

$2.67

$0.18

$0.45

$0.61

$0.61

$1.08

$0.39

$0.26

$48.80

$52.38

2016 by quarter:

1st Quarter

$2.09

$0.16

$0.38

$0.53

$0.53

$0.76

$0.31

$0.18

$33.45

$35.11

2nd Quarter

$1.95

$0.20

$0.49

$0.62

$0.63

$0.96

$0.33

$0.19

$45.59

$47.35

3rd Quarter

$2.81

$0.19

$0.47

$0.63

$0.67

$0.98

$0.38

$0.24

$44.94

$46.52

YTD 2016 Averages

$2.28

$0.18

$0.45

$0.59

$0.61

$0.90

$0.34

$0.20

$41.33

$43.00

(1)

Natural gas prices are based on Henry-Hub Inside FERC commercial

index prices as reported by Platts, which is a division of McGraw

Hill Financial, Inc.

(2)

NGL prices for ethane, propane, normal butane, isobutane and natural

gasoline are based on Mont Belvieu Non-TET commercial index prices

as reported by Oil Price Information Service.

(3)

Polymer-grade propylene prices represent average contract pricing

for such product as reported by IHS Chemical, a division of IHS Inc.

("IHS Chemical"). Refinery grade propylene prices represent

weighted-average spot prices for such product as reported by IHS

Chemical.

(4)

Crude oil prices are based on commercial index prices for West Texas

Intermediate ("WTI") as measured on the New York Mercantile Exchange

("NYMEX") and for Louisiana Light Sweet ("LLS") as reported by

Platts.

The weighted-average indicative market price for NGLs (based on prices
for such products at Mont Belvieu, Texas, which is the primary industry
hub for domestic NGL production) was $0.49 per gallon during the third
quarter of 2016 versus $0.45 per gallon for the third quarter of 2015.

Fluctuations in our consolidated revenues and cost of sales amounts are
explained in large part by changes in energy commodity prices. Energy
commodity prices fluctuate for a variety of reasons, including supply
and demand imbalances and geopolitical tensions.

A change in our consolidated marketing revenues due to lower energy
commodity sales prices may not result in a similar change in gross
operating margin or cash available for distribution, since our
consolidated cost of sales amounts would also change due to comparable
decreases in the purchase prices of the underlying energy commodities.

Enterprise Products Partners L.P.

Exhibit D

Distributable Cash Flow - UNAUDITED

($ in millions)

For the Three Months

For the Nine Months

Ended September 30,

Ended September 30,

2016

2015

2016

2015

Net income attributable to limited partners (GAAP)

$

634.6

$

649.3

$ 1,854.3

$

1,836.4

Adjustments to GAAP net income attributable to limited partners

to derive non-GAAP distributable cash flow:

Add depreciation, amortization and accretion expenses

391.9

372.8

1,155.3

1,147.7

Add distributions received from unconsolidated affiliates

99.0

96.9

333.5

362.4

Subtract equity in income of unconsolidated affiliates

(92.3 )

(103.1 )

(269.8 )

(302.5 )

Subtract sustaining capital expenditures (1)

(61.7 )

(84.3 )

(179.4 )

(195.8 )

(8.9 )

12.3

4.8

14.7

Add net losses or subtract net gains attributable to asset sales,

insurance recoveries and related property damage

Add cash proceeds from asset sales and insurance recoveries

16.0

1,531.4

43.9

1,537.3

6.9

4.3

28.0

15.8

Add non-cash expense attributable to changes in fair value of the

Liquidity Option Agreement

(26.2 )

2.2

42.1

(7.7 )

Add non-cash expense or subtract benefit attributable to changes

in fair value of derivative instruments

Add deferred income tax expense (benefit)

1.0

(1.6 )

5.3

(13.3 )

Add non-cash asset impairment charges

6.8

26.8

22.0

139.1

11.3

(5.7 )

31.7

(15.6 )

Add or subtract other miscellaneous adjustments to derive non-GAAP

distributable cash flow, as applicable

Distributable cash flow (non-GAAP)

978.4

2,501.3

3,071.7

4,518.5

Adjustments to non-GAAP distributable cash flow to derive GAAP

net cash flow provided by operating activities:

Add sustaining capital expenditures reflected in distributable cash

61.7

84.3

179.4

195.8

flow

(16.0 )

(1,531.4 )

(43.9 )

(1,537.3 )

Subtract cash proceeds from asset sales and insurance recoveries

reflected in distributable cash flow

Add or subtract the net effect of changes in operating accounts, as

(155.1 )

(377.2 )

(449.7 )

(627.9 )

applicable

Add or subtract miscellaneous non-cash and other amounts to

(15.2 )

12.6

(58.5 )

42.1

reconcile non-GAAP distributable cash flow with GAAP net cash flow

provided by operating activities, as applicable

Net cash flow provided by operating activities (GAAP)

$

853.8

$

689.6

$ 2,699.0

$

2,591.2

(1)

Sustaining capital expenditures are capital expenditures (as defined

by GAAP) resulting from improvements to and major renewals of

existing assets. Such expenditures serve to maintain existing

operations but do not generate additional revenues.

Distributable cash flow

Our management compares the distributable cash flow we generate to the
cash distributions we expect to pay our partners. Using this metric,
management computes our distribution coverage ratio. Distributable cash
flow is an important non-GAAP liquidity measure for our limited partners
since it serves as an indicator of our success in providing a cash
return on investment. Specifically, this liquidity measure indicates to
investors whether or not we are generating cash flows at a level that
can sustain or support an increase in our quarterly cash distributions.
Distributable cash flow is also a quantitative standard used by the
investment community with respect to publicly traded partnerships
because the value of a partnership unit is, in part, measured by its
yield, which is based on the amount of cash distributions a partnership
can pay to a unitholder. The GAAP measure most directly comparable to
distributable cash flow is net cash flow provided by operating
activities.

Enterprise Products Partners L.P.

Exhibit E

Adjusted EBITDA - UNAUDITED

($ in millions)

For the Three Months

For the Nine Months

For the Twelve Months

Ended September 30,

Ended September 30,

Ended September 30,

2016

2015

2016

2015

2016

Net income (GAAP)

$

643.1

$

657.7

$ 1,883.3

$ 1,864.9

$ 2,576.8

Adjustments to GAAP net income to derive non-GAAP Adjusted

EBITDA:

Subtract equity in income of unconsolidated affiliates

(92.3 )

(103.1 )

(269.8 )

(302.5 )

(340.9 )

Add distributions received from unconsolidated affiliates

99.0

96.9

333.5

362.4

433.2

Add interest expense, including related amortization

250.9

243.7

735.6

723.2

974.2

Add provision for income taxes

4.8

5.5

13.1

4.4

6.2

374.8

362.3

1,108.2

1,115.1

1,465.7

Add depreciation, amortization and accretion in costs and expenses

Add non-cash asset impairment charges

6.8

26.8

22.0

139.1

45.5

(8.9 )

13.6

4.8

17.5

6.2

Add non-cash net losses or subtract net gains attributable to

asset sales, insurance recoveries and related property damage

6.9

4.3

28.0

15.8

37.6

Add non-cash expense attributable to changes in fair value of the

Liquidity Option Agreement

(26.2 )

2.2

42.1

(7.7 )

31.4

Add non-cash expense or subtract benefit attributable to changes

in fair value of derivative instruments

Adjusted EBITDA (non-GAAP)

1,258.9

1,309.9

3,900.8

3,932.2

5,235.9

Adjustments to non-GAAP Adjusted EBITDA to derive GAAP net cash

flow provided by operating activities:

(250.9 )

(243.7 )

(735.6 )

(723.2 )

(974.2 )

Subtract interest expense, including related amortization,

reflected in Adjusted EBITDA

(4.8 )

(5.5 )

(13.1 )

(4.4 )

(6.2 )

Subtract provision for income taxes reflected in Adjusted EBITDA

(12.5 )

--

(51.9 )

--

(51.9 )

Subtract distributions received for return of capital from

unconsolidated affiliates

1.0

(1.6 )

5.3

(13.3 )

(2.0 )

Add deferred income tax expense or subtract benefit

(155.1 )

(377.2 )

(449.7 )

(627.9 )

(145.1 )

Add or subtract the net effect of changes in operating accounts,

as applicable

17.2

7.7

43.2

27.8

53.7

Add miscellaneous non-cash and other amounts to reconcile non-GAAP

Adjusted EBITDA with GAAP net cash flow provided by operating

activities

Net cash flow provided by operating activities (GAAP)

$

853.8

$

689.6

$ 2,699.0

$ 2,591.2

$ 4,110.2

Adjusted EBITDA

Adjusted EBITDA is commonly used as a supplemental financial measure by
our management and external users of our financial statements, such as
investors, commercial banks, research analysts and rating agencies, to
assess the financial performance of our assets without regard to
financing methods, capital structures or historical cost basis; the
ability of our assets to generate cash sufficient to pay interest and
support our indebtedness; and the viability of projects and the overall
rates of return on alternative investment opportunities.

Since Adjusted EBITDA excludes some, but not all, items that affect net
income or loss and because these measures may vary among other
companies, the Adjusted EBITDA data presented in this press release may
not be comparable to similarly titled measures of other companies. The
GAAP measure most directly comparable to Adjusted EBITDA is net cash
flow provided by operating activities.

Enterprise Products Partners L.P.

Exhibit F

Total Gross Operating Margin - UNAUDITED

($ in millions)

For the Three Months

For the Nine Months

Ended September 30,

Ended September 30,

2016

2015

2016

2015

Total gross operating margin (non-GAAP)

$ 1,312.0

$ 1,348.6

$

3,890.5

$

3,984.7

Adjustments to reconcile non-GAAP total gross operating margin

to GAAP total operating income:

(367.1 )

(351.1 )

(1,085.6 )

(1,082.0 )

Subtract depreciation, amortization and accretion expense amounts

not reflected in gross operating margin

(6.8 )

(26.8 )

(21.6 )

(139.1 )

Subtract non-cash asset impairment charges included in operating

expenses not reflected in gross operating margin

8.9

(12.3 )

(4.8 )

(14.7 )

Add net gains or subtract net losses attributable to asset sales,

insurance recoveries and related property damage not reflected in

gross operating margin

(42.0 )

(49.0 )

(121.0 )

(143.2 )

Subtract general and administrative costs not reflected in gross

operating margin

Total operating income (GAAP)

$

905.0

$

909.4

$

2,657.5

$

2,605.7

Total gross operating margin

We evaluate segment performance based on our financial measure of gross
operating margin. Gross operating margin is an important performance
measure of the core profitability of our operations and forms the basis
of our internal financial reporting. We believe that investors benefit
from having access to the same financial measures that our management
uses in evaluating segment results.

The term "total gross operating margin" represents GAAP operating income
exclusive of (i) depreciation, amortization and accretion expenses, (ii)
impairment charges, (iii) gains and losses attributable to asset sales,
insurance recoveries and related property damage and (iv) general and
administrative costs. Total gross operating margin includes equity in
the earnings of unconsolidated affiliates, but is exclusive of other
income and expense transactions, income taxes, the cumulative effect of
changes in accounting principles and extraordinary charges. Total gross
operating margin is presented on a 100 percent basis before any
allocation of earnings to noncontrolling interests. The GAAP financial
measure most directly comparable to total gross operating margin is
operating income.

Total gross operating margin excludes amounts attributable to shipper
make-up rights as described in footnote (4) to Exhibit A of this press
release.